For decades, the idea of transporting Nigerian natural gas across the Sahara to Algeria appeared to be one of those projects whose strategic importance was easier to explain than its practical implementation. The route was long, the financing complicated and the political coordination required between three countries far from straightforward. Yet the economic logic behind the Trans-Saharan Gas Pipeline (TSGP) has survived repeated delays, and recent developments have brought the project closer to physical implementation.
The renewed momentum is hardly coincidental. Since the European energy crisis of 2022, the search for alternative gas supplies has become a central concern for European governments. At the same time, African producers have been looking for ways to monetise resources that remain disconnected from international markets. For Algeria, the combination presents an opportunity that extends well beyond the export of additional gas: the country could consolidate its position as the principal energy gateway between West Africa and the Mediterranean.
The proposed 4,200-kilometre corridor would connect Nigeria's gas-producing regions to Algeria's Hassi R'Mel hub, crossing Niger along the way. Its ultimate design capacity is generally estimated at 30 billion cubic metres (bcm) annually, although a more gradual development, beginning with approximately 15–20 bcm, appears more consistent with the project's commercial and logistical realities.
The central question, however, is not simply whether Nigerian gas can reach Europe through the Sahara. It is whether the three countries can create an economically sustainable transportation system around which a much wider regional energy economy can develop.
Three countries, three different economic interests
The TSGP brings together three countries whose interests are complementary, but not identical.
Nigeria has enormous natural gas resources and an established LNG export industry. Yet the country continues to face difficulties expanding its domestic gas infrastructure, developing sufficient production capacity and satisfying both local consumption and international demand. An additional pipeline route would provide another option for monetising its reserves, reducing dependence on a single export channel.
Niger occupies the geographical centre of the project. Its territory provides the indispensable connection between Nigerian production and Algeria's existing gas network. For a landlocked country with limited industrial infrastructure, participation in a major international energy corridor could generate recurring transit income and create opportunities for domestic energy development.
Algeria, meanwhile, possesses something neither of its partners can easily replicate: an established gas transportation and export system connected directly to Mediterranean markets. Its national company, Sonatrach, has decades of experience in gas production, transmission, processing and international marketing. The country also has existing pipelines, LNG terminals and commercial relationships with European buyers.
The division of interests is therefore relatively clear. Nigeria needs additional routes to market, Niger needs infrastructure and economic returns from its geographical position, while Algeria has the opportunity to extend its energy influence southwards and reinforce its role in European supply security.
The success of the project will depend on whether these interests can be translated into a workable commercial arrangement.
Niger: the missing link and Algeria's strategic opportunity
The most difficult part of the TSGP may not necessarily be its longest section, but the section crossing Niger.
Depending on the route configuration used, the Nigerien segment is estimated at roughly 700–850 kilometres. It represents a substantial engineering and financial challenge for a country whose public resources are already stretched by competing development priorities.
Financing such infrastructure independently would place considerable pressure on Niger's budget. Yet without this section, the Nigerian and Algerian networks cannot be connected into a continuous export corridor.
This is where Algeria's involvement becomes particularly significant.
Sonatrach has been positioned to play a leading role in the construction of the Nigerien segment. Its participation could allow Niger to benefit from a major international pipeline without having to shoulder the entire immediate financial burden. It would also give Algeria an opportunity to develop a much deeper energy relationship with its southern neighbour.
The potential arrangement goes beyond the simple provision of engineering services. Sonatrach could become involved in technical studies, construction, maintenance and the wider development of Niger's hydrocarbon sector. Cooperation agreements involving Sonatrach subsidiaries and Niger's national petroleum company, SONIDEP, have already pointed towards a broader relationship.
There is, however, an important distinction between financing, construction and ownership. The three are often discussed together, although they represent different contractual responsibilities. The reported participation structure involving Sonatrach, Nigeria's NNPC and SONIDEP does not, by itself, establish who will finance each national section or how the resulting revenues will be distributed.
A possible arrangement would see Nigeria finance its remaining domestic connection, Algeria develop its national infrastructure, and Sonatrach assume a substantial role in the more difficult Nigerien section. Niger could participate through its national company, regulatory framework and agreed financial contributions.
Such a model would be particularly interesting if Algeria could use its financial and technical capacity to accelerate construction while allowing Niger to retain an economic stake in the corridor.
The strategic return for Algeria would not necessarily be limited to transportation fees. A successful partnership could open the door to wider cooperation in oil development, geological surveys, refining, petroleum distribution and electricity generation. In that sense, the pipeline could become the foundation of a long-term economic relationship rather than an isolated infrastructure project.
The economics: why the project does not need to start at 30 bcm
The TSGP is frequently discussed in terms of its ultimate capacity, but a pipeline's design capacity should never be confused with the volume it will actually transport during its first years of operation.
For a project crossing more than 4,000 kilometres, a phased approach makes considerable economic sense. An initial throughput of 15 bcm annually would already represent a significant commercial operation. Volumes could subsequently increase towards 20 bcm and eventually approach the proposed 30 bcm capacity as production, infrastructure and market commitments develop.
This gradual approach also changes the financing equation.
Rather than attempting to finance every component of the corridor simultaneously, the partners could concentrate on the sections that remain to be constructed and bring the system into operation progressively. The objective should be to avoid building infrastructure that remains underutilised for years while still ensuring that the initial configuration can accommodate future expansion.
The capital expenditure estimates deserve particular attention. Older project-wide figures, including estimates around $13 billion, should not automatically be treated as the definitive cost of the revised project. Route configuration, existing infrastructure, pipeline diameter, compressor stations, security requirements and the amount of new construction all influence the final investment.
A bottom-up estimate is therefore more useful than simply repeating a headline figure. In our working analysis, a cost range of approximately $7–8 billion has been explored for roughly 1,800–2,000 kilometres of construction. This is an analytical estimate, not an approved project budget, and it should be assessed section by section. The remaining national infrastructure, existing facilities and associated investments must be accounted for separately.
The financing of the Nigerien section is particularly important. An illustrative borrowing requirement of $2–3 billion for a major section of approximately 800 kilometres, financed over 30 years at 4%, would produce annual debt service of roughly $116–174 million under a standard amortisation model.
The actual financing conditions could differ considerably, but the calculation shows why the allocation of costs between the national companies matters so much.
The commercial question is then straightforward: can transportation revenues comfortably cover debt service, operating costs, compression and maintenance while leaving a sufficient return for the companies involved?
To understand the scale of the opportunity, consider 15 bcm of annual transportation. One billion cubic metres of natural gas contains approximately 35.3 million MMBtu, meaning that 15 bcm represents roughly 530 million MMBtu.
At illustrative transportation tariffs of $1.50–$2.00 per MMBtu, annual gross transportation revenue would range from approximately $795 million to $1.06 billion.
These are not revenues from selling the gas itself. They represent the hypothetical income generated by transporting it through the system. The value of the gas must be calculated separately, as must any trading margin earned by the companies purchasing and marketing it.
The distinction is essential. A cubic metre of gas may have a substantial market value, but that value does not automatically belong to the pipeline operator.
After debt service, compression, maintenance and other operating expenses, the remaining amount would determine the actual financial return. The project therefore needs a carefully negotiated tariff structure and reliable long-term transportation commitments. Even a relatively small change in tariff or utilisation can have a significant effect on profitability.
The underlying principle is that the TSGP does not necessarily need to operate at maximum capacity from the beginning. It needs sufficient contracted volumes to make its initial infrastructure commercially viable, with a credible path towards higher utilisation.
A new source of revenue for Niger
For Niger, the economic attraction of the pipeline lies partly in its ability to generate recurring income from the transportation of gas across its territory.
Transit revenue is particularly valuable because it can provide a source of foreign-currency income without requiring the country to become the principal financier of the entire corridor.
The potential amounts depend on the tariff negotiated for the Nigerien section, the volume transported and the contractual distribution of revenue between the project company and the participating national entities.
At 15 bcm annually, every $0.10 per MMBtu charged on the transported volume would represent approximately $53 million in gross annual revenue. At higher tariffs or larger volumes, the figures increase accordingly.
This provides a useful starting point for evaluating the opportunity, although actual Nigerien receipts cannot be established without the final transit and ownership agreements.
The long-term importance could extend beyond the direct financial return. A functioning pipeline would reinforce Niger's position as a transit country between two major energy economies and could support the development of additional infrastructure around its route.
For a landlocked country, the ability to participate in an international transportation network is itself an economic asset.
Hassi R'Mel and TransMed: Algeria's existing advantage
The strongest commercial argument for the Algerian route may lie at its northern end.
When Nigerian gas reaches Hassi R'Mel, it would enter an established Algerian gas system rather than a newly constructed export network. This is a considerable advantage. Algeria has spent decades developing the infrastructure required to transport gas towards the Mediterranean, including the TransMed pipeline connecting the country to Italy through Tunisia.
The importance of this existing infrastructure is difficult to overstate. A new pipeline connecting Nigeria directly to the Mediterranean would require not only the construction of thousands of kilometres of pipe but also the development of an entirely new northern export system. The TSGP, by contrast, could make use of infrastructure that already exists.
TransMed offers a particularly interesting route because Italy is already a major customer of Algerian gas and has sought to strengthen its position as an energy distribution hub for southern and central Europe.
From Italy, gas can enter the wider European network, potentially reaching markets such as Austria and Germany through interconnected infrastructure and commercial arrangements.
In our previous scenario analysis, we examined the possibility of approximately 12 bcm of Nigerian gas annually reaching European markets through the TSGP and TransMed, alongside a further 5 bcm potentially being directed towards Algerian LNG export infrastructure. This would represent a possible commercial configuration, not an announced supply contract or confirmed allocation.
Such a model would allow the project to serve more than one export channel, reducing dependence on a single destination and giving the partners greater flexibility in marketing the gas.
It would also reinforce Algeria's role as an intermediary between African production and European consumption.
The advantage, however, should not be exaggerated. Existing pipelines have finite capacity, and their utilisation depends on domestic Algerian consumption, existing export commitments, maintenance requirements and available transportation capacity. The additional volumes would have to be accommodated within the wider gas balance.
Europe's demand: an opportunity, but not a blank cheque
The European energy crisis transformed the strategic value of alternative gas routes. The disruption of Russian supplies pushed governments towards diversification, and Algeria became an increasingly important supplier to southern Europe.
Yet the European market should not be treated as an unlimited destination for additional African gas.
Future demand will depend on industrial consumption, electricity generation, storage requirements, LNG competition and the pace of the energy transition. Prices will also determine whether Nigerian gas transported across the Sahara can compete with other available supplies.
This is where the TSGP faces one of its most important commercial tests.
Nigeria already has the option of exporting gas through LNG facilities. A transcontinental pipeline must therefore offer an attractive combination of production costs, transportation tariffs and market access. Political support from European governments may help, but it cannot replace competitive economics.
Algeria's advantage is that it can offer access to an established network and an experienced gas marketing company. Sonatrach could potentially aggregate Nigerian gas, coordinate transportation and use its existing customer relationships to facilitate sales.
Whether this arrangement ultimately takes the form of long-term purchase agreements, transportation contracts or a combination of the two remains a commercial question.
The most sensible approach would be to secure credible buyers and long-term commitments before relying on optimistic assumptions about future European demand.
The part of the project that receives too little attention: southern Algeria
The TSGP is usually presented as an export project, but its domestic economic implications could be just as important.
A major energy corridor crossing southern Algeria creates an opportunity to rethink the industrial geography of the country. For decades, much of Algeria's industrial concentration has remained in the north, close to ports, established infrastructure and major population centres. The southern regions, despite their enormous geographical and energy potential, have remained less integrated into the country's industrial development.
A stronger gas transportation network could help change that equation.
Tamanrasset and the surrounding southern regions could become candidates for new industrial activity, provided that gas allocation, water supply, electricity, transport and market demand are addressed together.
Cement production is one of the more immediate possibilities. Large infrastructure programmes across the Sahara and the Sahel require substantial quantities of construction materials. Transporting cement over long distances from northern Algeria adds considerable logistical costs. A southern production facility could serve local infrastructure projects and potentially supply neighbouring markets.
Fertilizer production offers another opportunity. Natural gas is a fundamental feedstock for ammonia and nitrogen-based fertilizers, while agricultural development across the Sahel creates a potential regional market. A competitive fertilizer industry in southern Algeria could serve both domestic agriculture and neighbouring countries.
Steel processing and construction materials could follow. The initial stage might rely on semi-finished products transported from northern industrial centres, with local rebar processing, fabrication and the production of infrastructure components developing as demand grows.
Electricity generation would provide another important link. A stronger gas supply could support power generation and help establish a more reliable energy base for industrial development.
None of these industries would emerge simply because a pipeline passes nearby. They require investment, water, skilled labour, transport infrastructure and sufficient demand. But the TSGP could improve the economics of establishing them by strengthening the energy and logistics connections between southern Algeria and the wider Sahel.
This is perhaps the most interesting long-term dimension of the project. Instead of treating the Sahara as a territory through which energy merely passes, Algeria could use the corridor to establish new centres of production and regional trade.
Security and financing will determine the outcome
The ambitions surrounding the TSGP must be balanced against the realities of operating across the Sahel.
Political instability, armed groups, border insecurity and difficult operating conditions can increase construction costs and complicate the long-term maintenance of infrastructure. The Nigerien section is particularly exposed to these concerns.
Security risks affect more than the physical protection of a pipeline. They can delay contractors, increase insurance premiums, raise financing costs and discourage international lenders. A project can be technically sound and still struggle to reach financial closure if investors cannot obtain sufficient confidence in its long-term operation.
The three countries will therefore need a credible security framework, clear responsibilities and reliable mechanisms for emergency response and maintenance.
Financing is equally important. The project will require more than political declarations and engineering contracts. It needs a bankable structure supported by gas supply commitments, transportation agreements, predictable tariffs and a realistic construction schedule.
The ability of Sonatrach to assume a substantial role in the more difficult sections could help overcome some of the financial obstacles, particularly if it allows Niger to participate without carrying an unsustainable debt burden.
But the project must ultimately generate sufficient cash flow to pay for its operation, debt and maintenance. Strategic importance is an advantage when attracting partners; it is not a substitute for commercial viability.
A corridor that could reshape Algeria's southern economy
The future of the TSGP will probably be determined in stages rather than through a single decisive moment.
In a conservative scenario, financing and security constraints delay construction, while gas volumes develop slowly. The project remains strategically relevant but takes longer to generate significant returns.
In a more favourable scenario, the three national companies establish a workable financing and operating structure, Nigerian gas supply increases and the pipeline begins transporting commercial volumes. Algeria then benefits from additional throughput across its existing network, while Niger receives transit-related income.
The most ambitious outcome would go further. The TSGP could become the backbone of an integrated energy corridor connecting West African production to North African infrastructure and European markets. Southern Algeria would become more closely linked to the Sahel through industrial investment, electricity generation and regional trade.
This outcome would require complementary investments in roads, railways, power networks and industrial facilities. It would also require the three countries to maintain a degree of political and commercial cooperation over several decades.
The pipeline alone cannot deliver such a transformation. But it could provide the economic foundation around which these investments become more attractive.
For Algeria, the real opportunity is therefore not limited to transporting Nigerian gas to Europe. It is the possibility of combining its geographical position, existing export infrastructure and technical capabilities to become a central player in a new African energy corridor.
The Sahara has tradition
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